38 results about "Reservoir volume" patented technology

The embodiment of the invention provides an unconventional oil reservoir oil extraction contribution degree determination method and device, equipment and a medium. The method comprises the steps that the relation between the saturation degree of wet-phase fluid and capillary pressure in an oil reservoir is determined according to a plurality of reference capillary pressure curves; performing simulation analysis on the crack propagation direction and the seepage pressure in the oil reservoir volume fracturing process, and determining a three-dimensional propagation rule of the crack and artificial crack parameters; performing coupling processing on the three-dimensional fracture model and the matrix attribute model to obtain an oil reservoir geological engineering integrated model; establishing a numerical simulation model according to the relationship between the wet-phase fluid saturation and the capillary pressure and the reservoir geological engineering integrated model; performing numerical simulation on the oil reservoir development process through the numerical simulation model to obtain data simulation results of the oil reservoir in different development stages; the oil production contribution degrees of displacement and imbibition in different development stages of the oil reservoir are determined according to a data simulation result, and a theoretical basis and technical support are provided for oil reservoir exploitation.

Provided is a method for determining huff and puff fluid volumes in multi-scale spaces of shale oil reservoirs, including the following steps: rock sample pretreatment; porosity stress sensitivity testing; high pressure hg injection testing and nuclear magnetic resonance testing benchmarking; online nuclear magnetic resonance testing; data processing and analysis. Firstly, a changing law of multi-scale spaces of shale oil reservoirs with an effective stress is characterized through a pore stress sensitivity measurement and online nuclear magnetic resonance measurement combined experiment, and then the huff and puff fluid volumes of multi-scale spaces of shale oil reservoirs under a condition of a certain stimulated reservoir volume are calculated. A usage amount of a fracturing fluid for a fracturing horizontal well in the shale oil reservoir is determined from the perspective of giving full play to the imbibition replacement role of micro-nano pores.

A method for estimating a volume of a reservoir to be filled from a station for distributing a pressurized fluid including injecting a flow of pressurized fluid into the reservoir, determining a pressure variation in the reservoir, the pressure variation being determined with respect to an initial pressure, determining an amount of the fluid flow injected into the reservoir, and estimating the volume of the reservoir to be filled, on the basis of the amount of the fluid flow injected into the reservoir and on the basis of the pressure variation in the reservoir after the injection of the fluid flow. Wherein the volume of the reservoir to be filled is also estimated on the basis of an injection temperature, and on the basis of a temperature variation in the reservoir after the injection of the fluid flow.

The invention relates to the technical field of compressed air energy storage, in particular to a compressed air energy storage air reservoir volume calculation method and device and a medium. Setting a first gas reservoir volume; simulating the inflation process of the air reservoir, and calculating the air temperature of the first air reservoir; before the gas reservoir is deflated, determining the temperature change of the gas reservoir in the intermediate idle process; simulating the deflation process of the gas reservoir, and calculating the air temperature of a second gas reservoir; calculating the volume of a second gas reservoir according to the density difference of the gas reservoir before and after deflation; and comparing the first gas reservoir volume with the second gas reservoir volume, carrying out iterative calculation until the difference between the two volumes is smaller than or equal to a threshold value, and outputting the second gas reservoir volume as the final gas reservoir volume. According to the method, step-by-step integral iteration is carried out according to the adiabatic process, the volume of the gas reservoir can be accurately calculated, and unnecessary waste caused by too large volume of the gas reservoir is avoided.

The invention discloses a shale oil reservoir volume fractured horizontal well'stuffiness-drainage-production 'integrated physical simulation method, which comprises the following steps: drilling a shale oil reservoir full-diameter plunger rock sample, and completing rock sample pretreatment; wax-sealing the pretreated rock sample, and vacuumizing and pressurizing to saturate heavy water; displacing the saturated heavy water rock sample with the compounded in-situ crude oil until a bound water state; wax seals are removed, quartz sand is laid on the end faces of the rock samples, the rock samples are spliced to form a volume fracturing horizontal well physical model, and the volume fracturing horizontal well physical model is loaded into a rock sample holder; heavy water is pumped into the inlet end of the rock sample holder and pressurized, the inlet end is closed, and the well closing process after fracturing is simulated; and opening the inlet end of the rock sample holder, and simulating flowback production after fracturing. According to the experimental method, the'stuffy-drainage-mining 'physical process of the shale oil volume fractured horizontal well can be restored, fluid imbibition, flowing and occurrence rules are researched, and efficient development of shale oil reservoirs is guided.

Systems and techniques may be used to increase recovery of a geothermal energy resource. An example technique includes selecting a first borehole that extends from a surface of the earth into a first location in a geothermal reservoir, conditioning the first borehole by pumping a fluid into or out of the first borehole at a predetermined operating condition to change a property of the geothermal reservoir, and selecting a second borehole that extends from the surface of the earth into a second location in the geothermal reservoir. The example technique may include enhancing permeability of the geothermal reservoir by using a reservoir stimulation technique on the second borehole, wherein a property of a stimulated reservoir volume is controlled by the property of the geothermal reservoir that was changed by conditioning the first borehole.

This invention relates to water conservancy and hydropower engineering technology, and discloses a method for determining the volume of regulating reservoirs in multi-stage series hydropower stations with small tributary flow capacity and high requirements for coordinated operation of water volume between cascades. This method ensures the safety requirements of coordinated operation of the cascade power stations while also considering the economic efficiency of the project. The method for determining the volume of regulating reservoirs between strong hydraulic coupling multi-stage series hydropower stations provided by this invention includes: firstly, decomposing the total volume into normal operating regulating volume, emergency standby volume, and dead storage volume. The former is calculated based on the objective water volume deviation during power generation of the upstream and downstream power stations connected to the regulating reservoir, as well as the water volume deviation caused by unit output adjustments. The latter is determined based on the extreme accident condition of all power stations connected to the regulating reservoir being shut down in an emergency, combined with the emergency response time. Then, multiple total volume schemes under different emergency response times are proposed, and a reasonable regulating reservoir volume is recommended through comprehensive comparison from multiple dimensions, including safety, emergency response flexibility, and economy.

The invention relates to a method for explaining the real permeability of a reservoir in mottled carbonate rock. The method comprises the following steps: constructing a color standard of a compact part in a core of the mottled carbonate rock; identifying the core sample meeting the color standard; scanning the cross section of the core sample, calibrating a scanning result according to a core sample identification result, and calculating a reservoir proportion and a reservoir volume proportion of each cross section of the core sample; measuring the surface volume and the rock skeleton volume of the rock core sample, and correcting the real reservoir porosity of the rock core sample in combination with the reservoir volume ratio; measuring the permeability of the rock core sample, and correcting the real reservoir permeability of the rock core sample in combination with the reservoir proportion; and constructing a reservoir real porosity and reservoir real permeability chart, calculating the total porosity of the reservoir in the mottled carbonate rock according to the logging curve, and constructing a reservoir real permeability interpretation model in the mottled carbonate rock by combining the chart. According to the method, the blank of porosity and permeability logging interpretation of the patchy carbonate reservoir is filled up.

The invention provides an anti-perforation measuring point automatic control method and device for a settler steam stripping section, a terminal and a medium, and the method comprises the steps: obtaining the damage information of a positive pressure chamber measuring point of the deposit amount of the settler steam stripping section, and selecting a negative pressure chamber of the deposit amount of a spent riser, which has a preset potential difference with the positive pressure chamber of the deposit amount of the settler steam stripping section, as a borrowing measuring point; setting a closed-loop self-control reservoir quantity given value for the reservoir quantity of the steam stripping section; the set value of the reservoir quantity is adjusted according to the preset potential difference, so that the display data of the positive pressure chamber measuring point of the reservoir quantity of the steam stripping section of the settler after the borrowing measuring point is adopted are correspondingly corrected according to the display data before the borrowing measuring point is adopted. The service life of the steam stripping section measuring point pressure guiding pipe can be greatly prolonged, once the measuring point pressure guiding pipe is broken, effective control over the steam stripping section reservoir volume can be maintained by means of the measuring point of the spent riser, then the purpose of preventing a lifting section from being perforated is achieved, and the intrinsic safety of the device is ensured.

The ion source has an arc chamber defining an arc chamber volume. A reservoir is connected to the arc chamber and defines a reservoir volume. The reservoir receives a source species and defines a liquid within the reservoir volume. A conduit fluidly connects the reservoir volume to the arc chamber volume. First and second openings of the conduit open to the respective reservoir and arc chamber volumes. A heat source selectively heats the reservoir to melt the source species at a predetermined temperature. A liquid controller controls a first volume of liquid within the reservoir volume to define a predetermined supply of liquid to the arc chamber volume. The liquid controller is a pressurized gas source fluidly connected to the reservoir to supply gas to the reservoir and a predetermined amount of liquid to the arc chamber.

The invention discloses a relative permeability curve averaging method based on multi-sample virtual overall measurement. The relative permeability curve averaging method comprises the following steps: acquiring a relative permeability curve, a capillary force curve, absolute permeability and porosity of a sample as well as reservoir volume and rock stratum thickness data represented by each sample; drawing a capillary pressure-wet phase saturation curve graph and a relative permeability-wet phase saturation curve graph; assuming that the average wet phase saturation of all the samples under the condition of each specified capillary pressure value is calculated under the condition of overall measurement of the multiple samples, and determining the relative permeability value of each phase corresponding to the wet phase saturation; and respectively calculating the average value of the relative permeability of the wet phase and the average value of the relative permeability of the non-wet phase in the parallel and series arrangement directions of the rock strata to obtain an averaged relative permeability curve of all samples with anisotropic characteristics. The technical problem that the coarsening error of the relative permeability curve is too large is solved.

An injector and rail assembly for a common rail fuel injection system comprises a fuel injector comprising a head for receiving fuel and a neck region for supporting the head end, a common rail housing defining a reservoir volume for storing fuel at high pressure and including a stem defining a passage for delivering high pressure fuel from the reservoir volume to the head end of the fuel injector, the stem including a threaded portion, and an adaptable mounting arrangement for sealingly mounting the fuel injector to the stem of the common rail housing. The adaptable mounting arrangement comprises a primary nut mounted on the threaded portion of the stem and an annular seal being located on the stem, the primary nut having an internal channel and the head of the fuel injector being received within the internal channel.

The invention relates to the technical field of oil field exploration, in particular to a compact reservoir volume fracturing compressibility evaluation system. The system comprises a data acquisition device and an evaluation device, the data acquisition device is installed at one end of a drilling tool, the data acquisition device is in signal connection with the evaluation device, the evaluation device comprises a storage module, a calculation module assembly and a compressibility evaluation module, and data of the storage module is transmitted to the calculation module assembly. The calculation module assembly comprises a first brittleness index calculation module, a second brittleness index calculation module, an internal friction angle calculation module and a fracture toughness calculation module, and data of the data acquisition device is transmitted to the second brittleness index calculation module, the internal friction angle calculation module and the fracture toughness calculation module; and the data of the calculation module assembly is transmitted to the compressibility evaluation module. According to the evaluation system provided by the invention, the influence of the change of the compressive strength of the rock stratum during actual fracturing is considered, and compressibility evaluation can be carried out according to the real-time compression condition.

The invention discloses a device for simulating volume fracturing of a shale reservoir. The device comprises a simulated reservoir cavity, a turnover adjusting mechanism and a pressurized liquid filling mechanism, the simulation reservoir cavity is used for carrying out a volume fracturing simulation experiment; the overturning adjusting mechanism is arranged below the simulated reservoir cavity and is used for adjusting the inclination angle between the simulated reservoir cavity and the horizontal plane; and the pressurizing and liquid filling mechanism is connected with the simulation reservoir cavity and the turnover adjusting mechanism through pipelines, and is used for providing pressure during a simulation experiment and also providing drive for the turnover adjusting mechanism. The device provided by the invention solves the technical problem that fracturing simulation of any dip angle stratums is difficult to simulate.

The invention discloses a supercritical CO2 fracturing experiment method and system for shale. The method comprises the following steps: acquiring a natural crack distribution pattern of a shale fracturing test piece; testing the permeability of the shale fracturing test piece; then air tightness inspection before fracturing is carried out; loading set axial pressure and confining pressure, and stabilizing the pressure; injecting supercritical CO2 into the shale fracturing test piece at a constant temperature to carry out a fracturing experiment; testing the permeability of the fractured shale fracturing test piece; analyzing the shale fracturing permeability increasing effect according to the permeability data before and after fracturing; and obtaining the supercritical CO2 fracturing crack propagation form according to the fracturing crack distribution form and the natural crack distribution form. According to the method disclosed by the invention, experimental studies on a crack propagation mechanism and fracturing permeation enhancement in a shale supercritical CO2 fracturing process are carried out by virtue of an acoustic emission monitoring technology and an industrial CT technology, the feasibility of realizing shale gas reservoir volume fracturing transformation by virtue of supercritical CO2 fracturing is proved, and a reference is provided for exploring a shale gas reservoir anhydrous fracturing technology.

The invention relates to the technical field of petroleum and natural gas exploration, and discloses a method for improving tight oil reservoir volume fracturing productivity based on an imbibition mechanism, which comprises the following steps of: predicting fracture expansion conditions under different injection strategies by adopting a dynamic simulation technology to perform fracturing; parameter optimization is carried out in combination with machine learning, and imbibition medium injection parameters and fracturing parameters are designed; a nano-particle material is added into the imbibition medium, so that the contact area between the imbibition medium and crude oil is increased; a real-time monitoring system is introduced, and the soaking time is dynamically adjusted by monitoring the formation pressure change through a sensor; and the flow-back rate of the fracturing fluid is regulated and controlled through automatic control. According to the method, the formation pressure change is monitored in real time, and the current soaking state is evaluated by using a machine learning algorithm or an expert system, so that whether the imbibition process is completed or not can be more accurately judged, and the poor effect caused by unnecessary waiting time or too early completion of soaking is avoided.

The present application relates to the technical field of unconventional reservoir development and drainage, and provides a hydrophilic unconventional oil horizontal well volume fracturing post-soaking time design method, which comprises the following steps: S100, evaluating reservoir wettability and determining that the reservoir is a hydrophilic reservoir; S200, establishing a horizontal well segmented cluster fracturing post-reservoir fluid seepage basic physical model and determining basic conditions of the soaking time design method; S300, determining a soaking time calculation formula based on Darcy's law and seepage velocity; S400, collecting data values of parameters of the soaking time calculation formula; and S500, substituting the data values into the soaking time calculation formula to calculate equivalent reasonable soaking time. The method can achieve the technical effect that unconventional reservoir volume fracturing horizontal wells can be opened and oil can be seen.

An embodiment of the present invention discloses a method and device for predicting the ultimate recovery (EUR) of a shale oil volume fracturing well. The method includes: determining the oil production per unit flow pressure drop in a first preset time period and the oil production per unit flow pressure drop in a second preset time period; analyzing the oil production per unit flow pressure drop in the first preset time period and the oil production per unit flow pressure drop in the second preset time period by using at least one decline analysis method to determine a target decline analysis model; determining the predicted result of the oil production per unit flow pressure drop in a third preset time period based on the target decline analysis model; and determining the predicted productivity according to the predicted result of the oil production per unit flow pressure drop and the predicted result of the bottom-hole flowing pressure in the third preset time period. By implementing this solution, the accuracy of cumulative oil production prediction can be improved, the analysis time can be shortened, the prediction difficulty can be reduced, and a scientific basis can be provided for the production effect evaluation and development plan formulation of shale oil reservoir volume fracturing wells.

A multi-scale complex fracture network sand paving optimization design method belongs to the field of petroleum and natural gas engineering technology. It carries out three-dimensional fracture expansion numerical simulation by constructing a fine geomechanical model, and on this basis obtains the actual expansion morphology of the main fracture and branch fractures, and on this basis carries out the design of the conductivity experimental scheme, and further takes the production parameter as the optimal, obtains the conductivity ratio of the main fracture and branch fracture and the respective optimal fracture conductivity, and reversely calculates the lowest fracture sand paving concentration based on the optimal fracture conductivity, and realizes the sand paving design of the complex fracture network from the dual factors of economy and production. The present invention takes the complex fracture network of volume fracturing of unconventional oil and gas reservoirs as the research object, and optimizes the design of the conductivity of the fracture network sand paving to improve the conductivity of the complex fracture network and ensure the contribution of the complex fracture network to production. The invention has practical application value for the efficient fracturing design of unconventional reservoirs.

The invention relates to the field of hydraulic engineering gate control, and particularly discloses an integrated intelligent hoist which comprises a volume measuring and calculating module which divides gridding subunits based on a DEM (digital elevation model), performs curved surface integral in combination with terrain curvature parameters and real-time water depth, dynamically calculates reservoir volume, and calculates the volume of the reservoir; the problem of water storage capacity misjudgment caused by complex terrain and sludge interference in a traditional water level method is solved; the gate opening trigger module generates a flood discharge instruction through volume threshold value comparison; the flood discharge monitoring module extracts a gate contour line through high-definition video monitoring and calibrates the actual opening degree in combination with an image edge detection algorithm, and it is ensured that the overflowing area is accurate and controllable. And the automatic gate closing module calculates the flood discharge required duration according to the flood discharge water amount, the overflowing area and the flow velocity, dynamically corrects the gate closing time point, and prevents excessive flood discharge or insufficient water storage. According to the method, the limitation of a traditional warning water level method and fixed opening control is systematically solved, and the accuracy, safety and resource utilization efficiency of reservoir management are improved.

The invention provides a volume fracturing optimization method for improving the single well yield of a tight oil reservoir. The volume fracturing optimization method comprises the following steps that (1) well selection and layer selection are conducted according to the purpose of increasing the reservoir transformation volume; on one hand, natural fractures are relatively developed, the natural fractures are communicated through fracturing, and net-shaped fractures are achieved; the brittleness index of the reservoir is high, and rock is prone to shear slippage to form complex cracks; 2) optimizing fracturing fluid systems in a prepad fluid stage and a sand-carrying fluid stage; and (3) fracturing construction parameters are optimized. According to a conventional tight reservoir volume fracturing design method and an underground micro-seismic test result, aiming at a tight reservoir with poor reservoir physical properties, developed natural fractures and high brittleness index, the method aims at increasing the reservoir transformation volume and improving the fracture complexity, and on the basis of a conventional conventional volume fracturing large-liquid-amount, high-displacement and low-mucus design mode, the method is suitable for the volume fracturing design of the tight reservoir and the underground micro-seismic test result. And the fracturing fluid, the pumping sequence of fracturing parameters and the technological property are changed, the reservoir transformation volume is further increased, and the single well yield is increased.

Systems and techniques may be used to increase recovery of a geothermal energy resource. An example technique includes selecting a first borehole that extends from a surface of the earth into a first location in a geothermal reservoir, conditioning the first borehole by pumping a fluid into or out of the first borehole at a predetermined operating condition to change a property of the geothermal reservoir, and selecting a second borehole that extends from the surface of the earth into a second location in the geothermal reservoir. The example technique may include enhancing permeability of the geothermal reservoir by using a reservoir stimulation technique on the second borehole, wherein a property of a stimulated reservoir volume is controlled by the property of the geothermal reservoir that was changed by conditioning the first borehole.

The invention belongs to the technical field of petroleum and natural gas engineering, and provides a reservoir volume fracturing effect evaluation method and system, electronic equipment and a storage medium, and the method comprises the following steps: obtaining single mineral content, actual Young modulus and single mineral Young modulus in a rock sample; calculating the mineral dispersity, Young modulus difference degree and mineral adhesion degree of the rock sample according to the single mineral Young modulus of the rock sample in combination with the single mineral content and the actual Young modulus; calculating the fracture potential degree of the reservoir where the rock sample is located according to the Young modulus difference degree and the mineral adhesion degree; according to the mineral dispersity and the fracture potential degree of the reservoir, the fracture network complex index of the reservoir is calculated, and the volume fracturing effect of the reservoir is evaluated according to the fracture network complex index. The reservoir volume fracturing effect is evaluated by comprehensively considering the complexity of the natural fracture and the complexity of the fracture network formed by reservoir transformation, and the precision and accuracy of fracturing effect evaluation are improved.

The invention discloses a novel heterogeneous reservoir starting pressure and remaining oil distribution comprehensive analysis method, which relates to the technical field of reservoir analysis, and comprises the steps of using multi-scale data fusion, intelligent algorithm optimization and a dynamic monitoring and feedback mechanism to comprehensively analyze the starting pressure and the remaining oil distribution rule. The method has the advantages that high-precision data such as the permeability and the porosity obtained through micro-scale core analysis serve as basic input of reservoir numerical simulation, the simulation result is closer to the real reservoir seepage condition, the influence of the heterogeneity and the geologic structure of a reservoir on fluid flow is better considered in combination with macro-scale well logging seismic data, and the simulation result is more accurate. The precision and reliability of numerical reservoir simulation are improved, more powerful support is provided for formulation and optimization of a reservoir development scheme, and data such as porosity and oil saturation provided by microscopic core analysis are combined with reservoir volume and structure information reflected by macroscopic logging seismic data.

The invention relates to a power assembly and a vehicle, the power assembly comprises an oil pan and a liquid storage structure, the oil pan is used for containing lubricating oil, and the liquid storage structure is provided with a liquid inlet and a liquid outlet; the power assembly is configured to enable lubricating oil to be suitable for being conveyed to the liquid inlet of the liquid storage structure from the oil pan and suitable for being conveyed to the oil pan from the liquid outlet of the liquid storage structure. The oil pan is configured in the mode that the liquid storage amount of lubricating oil in the oil pan can be adjusted according to requirements. According to the technical scheme, the power assembly can increase the liquid storage amount of the lubricating oil in the liquid storage structure and reduce the liquid storage amount of the lubricating oil in the oil pan according to requirements so as to reduce oil stirring loss, or reduce the liquid storage amount of the lubricating oil in the liquid storage structure and increase the liquid storage amount of the lubricating oil in the oil pan so as to guarantee lubrication and cooling of the power assembly.

The embodiment of the present application discloses a method, device and computer storage medium for determining the porosity of a shale reservoir, and belongs to the technical field of shale gas exploration and development. The method includes: obtaining well logging data of a target single well for a target shale reservoir; determining, in sequence, a first change relationship between the organic carbon content and the reservoir density in the target shale reservoir, and a second change relationship between the organic carbon content and the reservoir volume in the target shale reservoir according to the well logging data; determining the porosity of the target shale reservoir after eliminating the influence of the organic carbon content in the target shale reservoir according to the first change relationship, the second change relationship and the well logging data. The embodiment of the present application determines the porosity of the target shale reservoir after eliminating the influence of the organic carbon content in the target shale reservoir through the relationship between the organic carbon content and the reservoir density in the target shale reservoir and the relationship between the organic carbon content and the reservoir volume, thereby improving the accuracy of determining the porosity of the shale reservoir.

A material balance-based method for evaluating the effectiveness of volumetric fracturing in unconventional reservoirs is proposed. First, a set of material balance equations for volumetric fracturing in unconventional reservoirs is established. Then, by designing a calculation process and developing a multi-well synchronous solution program, key evaluation parameters for the volumetric fracturing effect of each well are obtained. Finally, the proportion of injected fluid in each volume during the volumetric fracturing process is quantitatively analyzed, resulting in theoretical charts of volumetric fracturing effect evaluation parameters under different construction parameters. Taking a typical well group in an actual unconventional reservoir block as an example, the volumetric fracturing effect at different well network development stages is quantitatively evaluated. This method, based on material balance, offers a simple parameter input and calculation process, and can provide timely guidance for well network adjustments and comprehensive management of unconventional oil and gas reservoirs.

The invention relates to the technical field of reservoir logging evaluation, in particular to a reservoir water saturation evaluation method based on a volume model, electronic equipment and a storage medium, and the method comprises the following steps: determining shale resistivity, formation water resistivity, reservoir shale content and reservoir porosity; and substituting the shale resistivity, the formation water resistivity, the reservoir shale content and the reservoir porosity into the reservoir volume model response equation to obtain the relative volume of the porosity occupied by the formation water and the relative volume of the porosity occupied by the formation oil, and determining the water saturation of the reservoir.

The invention discloses a petroleum reservoir porosity dynamic analysis method based on logging-while-drilling data, belongs to the field of petroleum and natural gas exploration and development, and is suitable for complex well types such as horizontal wells and the like. The method comprises the following steps: firstly, constructing a logging-while-drilling data real-time acquisition subsystem to complete multi-source data acquisition, transmission, analysis and preprocessing; calculating an initial porosity and a specific surface by combining a capillary bundle model, modeling, and calculating reservoir volume strain and sand migration parameters at the same time; fusing the parameters to construct a dynamic porosity model, solving by using a Newton iteration method, and further constructing a porosity-depth-time three-dimensional dynamic model and visualizing the porosity-depth-time three-dimensional dynamic model; and finally, constructing an analysis system containing multiple modules, wherein the modules interact through the data service middleware. According to the method, the porosity can be dynamically analyzed in real time, the calculation precision is improved, changes are visually presented, and data interaction and application convenience is guaranteed.

This invention discloses a method and system for spatializing flood storage capacity based on remote sensing data, belonging to the field of flood storage capacity spatialization technology. The method includes: determining spatial raster data of rainfall, runoff, and lake / reservoir volumes for the vegetation ecosystem of the target area to be evaluated, based on remote sensing data; and then determining the spatialized flood storage capacity of the target area based on these data. This invention utilizes the rasterizable nature of remote sensing data to achieve the purpose of spatialized calculation of flood storage capacity.